Horizontal directional drilling area network and methods

ABSTRACT

A drilling area network hub is located proximate to a drill rig and includes an uphole transceiver in bidirectional communication with a downhole transceiver by utilizing the drill string as an electrical conductor. Certain information is collected including rig-based and/or location information. At least one field report is generated based on the certain information to characterize at least one of an inground operation, an operational condition of the downhole transceiver, an operational condition of the uphole transceiver, and an operational condition of the drill rig. A drilling area network server receives the field report from the Internet at a remote location and can generate a custom report and/or recommended actions based on field data. Region specific parameters can be applied to the operation of a drilling system. The drilling area network hub can transfer data logs to the remote location according to assigned priorities.

RELATED APPLICATION

The present application is a continuation application of U.S. patentapplication Ser. No. 14/949,712 filed on Nov. 23, 2015, which is acontinuation application of U.S. patent application Ser. No. 13/734,841filed on Jan. 4, 2013 and issued as U.S. Pat. No. 9,194,228 on Nov. 24,2015, which claims priority from U.S. Provisional Patent ApplicationSer. No. 61/584,231 filed on Jan. 7, 2012, each of which areincorporated herein by reference in their entirety.

BACKGROUND

The present application is at least generally related to horizontaldirectional drilling operations and, more particularly, to a system,apparatus and methods involving a horizontal directional drilling areanetwork.

Traditional horizontal directional drilling systems often utilize anumber of components such as an inground transmitter, a drill rig and ahandheld locator. Applicants recognize that communications between thesecomponents have typically been limited to minimum functionalrequirements that are necessary to successfully complete a particularinground operation such as, for example, forming a borehole andsubsequent back-reaming to install a utility within the ground.

Because of the complexity of the equipment that makes up an overallmodern horizontal directional drilling system, an operator can beresponsible for many aspects of system operation, often with little orno external or remote oversight. Applicants recognize a number ofconcerns in this regard. One area of concern relates to component andsystem maintenance. In some cases, component or system failure canresult due to a failure to follow manufacturer specified maintenanceprocedures. Another area of concern resides in the need to carefullymonitor certain operational parameters as an inground operation isperformed to insure that an installed utility is not damaged by theinground operation, to ensure that an inground operation is performed incompliance with a permit or simply to provide supervisory oversight froma remote location, for example, to allow one supervisor to overseemultiple boring projects at once.

Moreover, recording the operational parameters of an inground operationinto an “as-built” drawing is becoming a common practice, and in somecases is now a requirement imposed on contractors as a condition tobeing awarded a project or as a condition to being paid for suchproject. Applicants recognize that apparatus for recording such data andproducing such as-built drawings in horizontal directional drillingprojects are currently very limited, and do not allow for remote datastorage.

Still another area of concern involves the wide range of regulationsthat can be imposed by governmental entities with respect to performingan inground operation in a given region, as will be further discussed.

Finally, Applicants recognize that as competition increases in thehorizontal directional drilling industry, current systems would limitthe ability of companies who provide products and services in thisindustry to increase sales opportunities and to better service theircustomers.

The foregoing examples of the related art and limitations relatedtherewith are intended to be illustrative and not exclusive. Otherlimitations of the related art will become apparent to those of skill inthe art upon a reading of the specification and a study of the drawings.

SUMMARY

The following embodiments and aspects thereof are described andillustrated in conjunction with systems, tools and methods which aremeant to be exemplary and illustrative, not limiting in scope. Invarious embodiments, one or more of the above-described problems havebeen reduced or eliminated, while other embodiments are directed toother improvements.

Generally, an arrangement, apparatus and associated methods aredescribed for use in conjunction with a system that performs horizontaldirectional drilling, including a drill rig and a subsystem formonitoring the location of an inground tool along an undergroundborepath and other operational parameters relating to the undergroundborepath. A downhole transceiver is supported proximate to the ingroundtool which is configured for bidirectional communication includingreceiving operational instructions from above ground and transmittinglocating and operational data. A drilling area network hub can belocated at the drill rig and includes an uphole transceiver that isconfigured for data communication with the downhole transceiver forbidirectional communication between the inground tool and the drill rigby utilizing the drill string as an electrical conductor, a datacommunication arrangement at least for monitoring at the drill rig togenerate certain information including at least one of locationinformation and rig-based information, a processor for collecting thecertain information for generating at least one field report based onthe certain information which field report is related to at least one ofthe inground operation, an operational condition of the downholetransceiver, an operational condition of the uphole transceiver, and anoperational condition of the drill rig, and an Internet connectionarrangement that is configurable at least for intermittent datacommunication with the Internet for transferring the field report to aremote location.

In another aspect of the disclosure, a drilling area network hub islocated proximate to the drill rig at least for collectingsystem-generated borepath data that characterizes the borepath andsystem-related operational data for generating at least one field reportand one or more recommended actions based on the borepath data and theoperational data to characterize at least one of the inground operationand an operational condition of the drill rig. An Internet connectionarrangement can form part of the drilling area network hub and isconfigured at least for intermittent data communication with theInternet for transferring the field report to a remote location. Adrilling area network server receives the field report from the Internetat the remote location and generates a custom report based on the fieldreport.

In another aspect of the disclosure, an apparatus and associated methodmonitor a horizontal directional drilling system that is configured toperform an inground operation, including a drill rig and a subsystem formonitoring the location of an inground tool along an undergroundborepath and other operational parameters relating to the undergroundborepath. An application is configured to receive system-generatedborepath data that characterizes the underground borepath andsystem-related operational data at a location that is remote from thesite of the underground borepath via remote electronic datatransmission, and to generate at least one of a customized report andone or more recommended actions based on the borepath data and theoperational data.

In still another aspect of the disclosure, an apparatus and associatedmethod are configured for customizing one or more configurablecomponents of a horizontal directional drilling system based on regionspecific parameters. The horizontal directional drilling system includesa drill rig and a subsystem for monitoring the location of an ingroundtool along an underground borepath and other operational parametersrelating to the underground borepath. A geographic database of regionspecific parameters specifies operational parameters based on locationfor one or more components of the system. An arrangement is provided foridentifying a current location of at least one locatable component ofthe system in the region and correlating the current location with thegeographic database to identify a set of local requirements for thecurrent location. A controller customizes at least one operationalparameter of the one or more configurable components based on thecurrent location to conform to the set of local requirements.Operational parameters which can be configured as a result of suchrequirements may include, without limitation, transmission frequency andmaximum transmission power. In a feature, the system can beautomatically configured to conform to the region specific parameters.

In yet another aspect of the disclosure, an arrangement and associatedmethod monitor a system that performs horizontal directional drilling,including a drill rig and a subsystem for monitoring the location of aninground tool along an underground borepath and other operationalparameters relating to the underground borepath. A drilling area networkhub is located proximate to the drill rig for generating a plurality ofdata logs of differing types that characterize the inground operation asthe inground operation is performed along a borepath and the drillingarea network hub is configured at least for intermittent datacommunication with a remote location. A priority table applies apriority ranking to the differing types of the data logs such that thedrilling area network hub transfers the data logs to the remote locationaccording to the priority table.

BRIEF DESCRIPTIONS OF THE DRAWINGS

Exemplary embodiments are illustrated in referenced figures of thedrawings. It is intended that the embodiments and figures disclosedherein are to be illustrative rather than limiting.

FIG. 1 is a diagrammatic view, in elevation, of a drilling area networkand its components operating as part of a horizontal directionaldrilling system according to the present disclosure.

FIG. 2 is a block diagram illustrating an embodiment of the componentsof the drilling area network according to the present disclosure.

FIG. 3 is a flow diagram that illustrates an embodiment of a method forperforming drilling area network updates.

FIG. 4 is a block diagram that illustrates an embodiment of a drillingarea network (DAN) hub according to the present disclosure.

FIG. 5 is a flow diagram that illustrates an embodiment of a method forthe operation of the drilling area network hub of FIG. 4.

FIG. 6 is a block diagram that illustrates an embodiment of a drillingarea network (DAN) server according to the present disclosure.

FIG. 7 is a flow diagram that illustrates an embodiment of a method forthe operation of the drilling area network server of FIG. 7.

DETAILED DESCRIPTION

The following description is presented to enable one of ordinary skillin the art to make and use the invention and is provided in the contextof a patent application and its requirements. Various modifications tothe described embodiments will be readily apparent to those skilled inthe art and the generic principles taught herein may be applied to otherembodiments. Thus, the present invention is not intended to be limitedto the embodiment shown, but is to be accorded the widest scopeconsistent with the principles and features described herein includingmodifications and equivalents. It is noted that the drawings are not toscale and are diagrammatic in nature in a way that is thought to bestillustrate features of interest. Descriptive terminology may be adoptedfor purposes of enhancing the reader's understanding, with respect tothe various views provided in the figures, and is in no way intended asbeing limiting.

Turning now to the drawings, wherein like items may be indicated by likereference numbers throughout the various figures, attention isimmediately directed to FIG. 1, which illustrates an embodiment of adrilling area network, generally indicated by the reference number 10,used in conjunction with a system 12 for performing an ingroundoperation. The system includes a portable device 20 that can be carriedby an operator 22. Device 20 is configured for receiving anelectromagnetic locating signal 30 that is transmitted from an ingrounddevice such as, for example, a boring tool 32. The locating signal canbe a dipole signal. In this instance, the portable device cancorrespond, for example, to the portable device described in any of U.S.Pat. Nos. 6,496,008, 6,737,867, 6,727,704, as well as U.S. PublishedPatent Application no. 2011-0001633 each of which is incorporated hereinby reference. In view of these patents, it will be appreciated that theportable device can be operated in either a walkover locating mode, asillustrated by FIG. 1, or in a homing mode having the portable deviceplaced on the ground, as illustrated by the U.S. Pat. No. 6,727,704patent. While the present disclosure illustrates a dipole locating fieldtransmitted from the boring tool and rotated about the axis of symmetryof the field, the present disclosure is not intended as being limitingin that regard. Many suitable system configurations can be implemented.For example, a locating field can be transmitted from the portabledevice itself as seen at least in FIGS. 18a and 18b of U.S. Pat. No.7,425,829 and FIG. 3b of U.S. Pat. No. 7,775,301 each of which isincorporated by reference. It is noted that a magnetic dipole field isrotated in the latter patents by rotation about an axis that istransverse to the axis of symmetry of the field. In such a system, areceiver in the boring tool can detect the rotating magnetic fieldtransmitted from the portable device such that the receiver in theboring tool generates position related data that is transferred in asuitable way to the drill rig. Still another type of system does notrequire a portable device for purposes of tracking the inground tool ortransmitting a locating signal. For example, some prior art systems cantrack the location of an inground tool by integrating orientationparameters transferred from the inground tool to the drill rig throughthe drill string and/or by utilizing an inertial navigation system thatis supported by the inground tool. Accordingly, the system andassociated methods described herein are considered by Applicants ascapable of utilizing any information that is generated by any componentof the system so long as the information is related to the operationthat is being performed. The portable device or any other above groundsystem component can include a GPS (Global Positioning System) receiverfor determining the position of the components at any appropriate timeduring operation. The GPS components may be survey grade in order toprovide enhanced position determination accuracy.

Returning to the discussion of FIG. 1, locating signal 30 can bemodulated with information generated in the boring tool including, butnot limited to position orientation parameters based on orientationsensor readings, temperature values, pressure values, battery status,tension readings in the context of a pull-back operation, and the like.In this regard, portable device 20 includes a telemetry arrangementhaving a telemetry antenna 40 that transmits a telemetry signal 42. Forthe moment, it is sufficient to note that the telemetry signal can beused to convey any information that is modulated on the locating signalto other above ground locations such as the drill rig. It should beappreciated that the inground device is not limited to a boring toolsince other types of inground device can transmit a locating signal.Another suitable type of inground device, for example, is a reamer foruse in a pull-back operation to install a utility line in a previouslyformed borehole. It is noted that, as an alternative to modulating thelocating signal, the subject information can be carried up the drillstring to the drill rig using electrical conduction such as awire-in-pipe arrangement. In another embodiment, bi-directional datatransmission can be accomplished by using the drill string itself as anelectrical conductor. By way of example, a current transformer 50 can bein electrical communication with console 120 and in electromagneticcommunication with drill string 100. It is noted that such a currenttransformer at the drill rig is well-known to those of ordinary skill inthe art and typically uses a toroidal core surrounding the drill string.The toroidal core supports a toroid winding that couples to theelectrically conductive drill via the core so that the drill stringserves as a single turn winding to complete the current transformer. Anadvanced embodiment of a drill string communication system is describedin commonly owned U.S. application Ser. No. 13/733,097, filed on Jan. 2,2013, which is incorporated herein by reference in its entirety. Ineither case, all information is made available to console 120 at thedrill rig.

Still referring to FIG. 1, system 12 further includes drill rig 80having a carriage 82 received for movement along the length of anopposing pair of rails 83. Boring tool 26 includes an asymmetric face 84and is attached at an opposing end to a drill string 86. Generally,drill string 86 is made up of a plurality of removably attachable drillpipe sections such that the drill rig can force the drill string intothe ground using movement in the direction of an arrow 88 and retractthe drill string responsive to an opposite movement. Joints 90 betweenadjacent ones of the drill pipe sections in the drill string arediagrammatically shown as vertical lines. The drill pipe sections candefine a through passage for purposes of carrying a drilling mud orfluid 92 that is emitted from the boring tool under pressure to assistin cutting through the ground as well as cooling the drill head.Generally, the drilling mud also serves to suspend and carry outcuttings to the surface along the exterior length of the drill string.Steering can be accomplished in a well known manner by orientingasymmetric face 84 such that the boring tool is deflected in a desireddirection in the ground responsive to forward, push movement which canbe referred to as a “push mode.” Rotation or spinning of the drillstring by the drill rig will generally result in forward or straightadvance of the boring tool which can be referred to as a “spin” or“advance” mode.

The present example contemplates movement of the boring tool within amaster XYZ coordinate system. For purposes of simplicity, in the presentexample, the X axis can be at least generally coextensive with thesurface of the ground and lie generally above an intended path of theboring tool, however, any other suitable arrangement of coordinate axesmay be adopted. The origin of the master coordinate system is specifiedby reference numeral 100, and can coincide with the point where theboring tool enters the ground, although the coordinate axes are offsetin the present view for purposes of illustrative clarity. While aCartesian coordinate system is used as the basis for the mastercoordinate systems employed by the various embodiments which aredisclosed herein, it is to be understood that this terminology is usedfor descriptive purposes and that any suitable coordinate system may beused. As noted, the X axis extends forward whereas the Y axis extends tothe right when facing in the forward direction along the X axis and theZ axis is directed downward.

The drilling operation can be controlled by an operator (not shown) at acontrol console 120 which itself includes a telemetry transceiver 122connected with a telemetry antenna 124 for transmitting a telemetrysignal 125, a display screen 126, an input device such as a keyboard130, a processing arrangement 132 which can include suitable interfacesand memory as well as one or more processors. A plurality of controllevers 134, for example, control movement of carriage 82 as well asother functions of the drill rig. In an embodiment, screen 126 can be atouch screen such that keyboard 130 may be optional. It is noted thattelemetry systems such as, for example, as formed between device 20using signal 42 and the drill rig using signal 125 are typically subjectto regulatory control at least with respect to transmission power andtransmission frequency. Because this telemetry system can be configuredon-the-fly with respect to both transmission power and frequency, it canbe considered as one configurable component of the system.

Continuing to refer to FIG. 1, drilling area network (DAN) 10 can beconsidered to include components of the on-site telemetry systemdescribed above which can provide wireless bidirectional communicationbetween portable device 20 and telemetry transceiver 122 at the drillrig. The DAN further comprises a DAN hub 210 that can be located at anysuitable physical location such as, for example, in console 120 at thedrill rig. The DAN hub is in data communication with drill rig 80 aswell as with portable device 20 via telemetry transceiver 122. In oneembodiment, drill rig 80 can be equipped with a controller area networkbus (CAN-bus) for purposes of enabling and facilitating datacommunication. The CAN-bus operates according to a message-basedprotocol, which was initially designed for automotive applications buthas rapidly expanded to use in other areas such as industrial andmedical equipment. While specific details of the operation of theCAN-bus are beyond the scope of the present disclosure, it should beappreciated that the CAN-bus can readily be implemented for purposes ofmonitoring virtually any aspect of the operation of drill rig 80, atleast some of which purposes will be described in detail at one or moreappropriate points below. Moreover, it is noted that the DAN hub can beconfigured to cooperate to exchange information with any arrangementthat is used to monitor and control the drill rig and is not limited tothe CAN-bus.

DAN hub 210 is configurable for connection to the Internet 212 such as,for example, using a wireless connection as indicated by an arrow 214.The connection can be accomplished in any suitable manner such as, forexample, using a cellular data connection, satellite data connection,WiFi connection according to well-known IEEE 802.11 standards or anyother suitable form of wireless connection that is either currentlyavailable or yet to be developed. In this regard, a great deal offlexibility can be provided to the system operator. It should beappreciated that the specific type of Internet connection(s) that areavailable can vary from the location of one inground operation to thenext such that a given DAN can be implemented to accommodate more thanone type of Internet connection. Moreover, the system operator can evenelect to connect via WiFi to a cellular telephone that is configured toserve as a WiFi hotspot which can provide significant data bandwidth. ADAN server 220 can communicate with DAN hub 210 via the Internet. Forexample, the DAN hub can send operational data to the DAN server usingweb services, as will be further described. The DAN server can connectto the Internet in any suitable manner as illustrated by a connection222. Users can connect to the DAN server in any suitable way. A firstuser computer 226 is shown directly connected to the DAN server via LAN230 while a second user computer 232 is shown connected to the Internetvia a connection 234 for remote or WAN connection to DAN server 220.User access to the DAN server can be via a standard Internet connection.While only two users have been shown for purposes of illustrativeclarity, it should be appreciated that the DAN server can support alarge number of users.

FIG. 2 is a block diagram that illustrates an embodiment of DAN 10 in away that is consistent with FIG. 1. In this regard, it should beappreciated that the locating signal can be transmitted from atransceiver 32′ that is removably installed in boring tool 32 of FIG. 1.In an embodiment, above ground data communication with transceiver 32′can be facilitated by an infrared (IrDA) connection 240 between thetransceiver and the portable device. Such an infrared connection can beused, by way of example, to program the transceiver prior to aparticular inground operation. Features of the transceiver that can beprogrammable include but are not limited to the carrier frequency of thelocating signal, the signal strength and the baud rate. It should beappreciated that the connection to the drill head transmitter can bemade in any suitable manner and is not limited to infrared. For example,this connection can be implemented via Bluetooth. In another embodiment,below ground communication with drill head transceiver 32′ (shown inphantom) may occur using a communication link 241 that can couple datasignals onto the drill string as electrical signals for bidirectionaltransfer using the drill string as an electrical conductor. Applicantshave developed advanced drill string communication systems such as aredescribed in above incorporated U.S. patent application Ser. No.13/733,097. In an embodiment, drill head transceiver 32′, which can bereferred to interchangeably as a downhole transceiver, can be inelectrical communication with a downhole current transformer 50′ toimplement link 241 thereby facilitating bidirectional communication withan inground end of the drill string in the same manner as previouslydescribed current transformer 50. Another suitable type of couplingarrangement proximate to the inground end of the drill string can forman electrically isolated gap in the electrical continuity of the drillstring across which transceiver 32′ is bridged. While such electricallyisolating gaps are known in the art, advanced mechanisms are described,by way of example, in U.S. patent application Ser. No. 13/593,439, filedon Aug. 23, 2012, which is commonly owned with the present applicationand incorporated herein by reference. CAN-bus 242 is explicitly shown asextending between DAN hub 210 and drill rig 80. It should be appreciatedthat the CAN-bus can be implemented as part of processing section 132 atthe drill rig. Telemetry signal 42 can be implemented in the UHF band,for example, at 464.5 MHz and is therefore designated accordingly. Anysuitable set of parameters, including combinations of the parametersshown in FIG. 2, can be monitored with respect to the operation of thedrill rig such as, for example, hydraulic pressure(s), mud pressure, mudflow rate, drill RPM, drill string length and drill string clamp status.

Referring collectively to FIGS. 1 and 2, DAN hub 210 can serve in themanner of a central controller for data flow in the Drilling AreaNetwork. The DAN hub can collect data from portable device 20,transmitter 32′, drill rig 80 and any other system component ofinterest. Collected data can be transferred to the DAN server forfurther processing and viewing using DAN services, yet to be described.The DAN hub can receive remote data from the DAN server for furtherprocessing, viewing and/or forwarding to portable device 20, drill headtransmitter 32′ or drill rig 80. Data that can be collected by the DANHub and remotely stored includes but is not limited to:

-   -   Data logs that are created during boring operations that include        information such as:        -   The depth of the drill head at various points during a bore        -   The pitch of the drill head at various points during a bore        -   The temperature of the drill head at various points during a            bore        -   The annular fluid pressure at the drill head at various            points during a bore        -   The tension on a pull-back utility at various points during            a pull-back        -   GPS coordinates of the portable device, drill rig and any            other system components        -   Status of the portable device or locator        -   Status of drill head transmitter or transceiver            With regard to data logs, different types of data logs can            be handled in different ways. As one example, tension data            in a pull-back operation can be considered as a high            priority such that a tension data log can be transferred            prior to other types of data logs. Transfer of data logs can            be prioritized, for example, based on predefined threshold            limits for each data log type. For example, a fluid pressure            log can be associated with a maximum pressure value. If the            maximum pressure is violated, the pressure log can be            flagged in a suitable manner and transferred to the DAN            server. In the instance of violation of a predefined            threshold, the associated data log can be transferred            incrementally. A predefined user can also be notified            whenever a predefined threshold is violated, for example, by            email. Table 1 illustrates an embodiment of one priority            system, although any suitable embodiment can be used without            limitation.

TABLE 1 Priority Assignment Type of Data Log Threshold Value 1 Pull-backTension Utility Based T_(max)/ΔT_(max) 2 Annular Fluid PressureUtility/Inground Operation Based 3 Drillhead Temperaturet_(max)/Δt_(max) 4 As-Built Data N/A 5 DAN Component Status N/A and Data6 GPS Coordinates (+/−)D_(min)

Data log transfer can proceed according to Table 1 during normaloperation of the system. In the event that thresholds for two or moredifferent types of data logs are simultaneously violated or at leastviolated in an overlapping manner, arbitration can be performedaccording the priority assignments of Table 1. In an embodiment,threshold values can be determined as a function of the productspecifications for the utility that is being installed during apull-back operation. For example, when pulling plastic pipe, thepull-back tension threshold can be far different than the threshold ascompared to pulling steel pipe. Accordingly, Table 1 indicates that thethreshold for pull-back tension can be utility based. Given themanufacturer specification for a utility, a maximum pull-back tensionT_(max) can be specified. Either alone or in combination with T_(max), amaximum rate of change in tension ΔT_(max) can be specified. Likewise,the resistance of a utility to annular fluid pressure can vary greatlyon the basis of the type of material from which the utility is formed.Hence, Table 1 indicates that the threshold for annular fluid pressurecan be based on the type of utility and/or the type of ingroundoperation that is being performed. Again, a maximum annular pressurevalue and/or a maximum rate of change in annular pressure can bespecified.

It is further recognized that the annular pressure can be subject todifferent thresholds with respect to drilling a pilot bore to form aborepath versus a pull-back operation to install a utility along thatsame borepath. In an embodiment, at least some threshold values can beprovided on the basis of multiple copies of Table 1 that can be indexedbased on different types of inground operations as well as the type ofutility that is being installed. In the instance of drillheadtemperature, a threshold can be based on a maximum temperature t_(max)and/or a maximum rate of temperature change Δt_(max). By way ofnon-limiting example, a maximum temperature of 45° C. can be useful, forexample, based on the temperature limitations of any electronics carriedby the inground tool. Such a fixed threshold is useful to indicate thatthe temperature is slowly trending upward. The operator can take actionssuch as slowing down the advance rate/rotation rate of the drill stringwhile drilling or back reaming and/or increasing the volume of drillingfluid to provide cooling. As another example for Δt_(max), a temperaturerise from 30° C. to 60° C. in the span of one minute can serve as auseful threshold. This type of threshold is useful, for example, whenrock is encountered and the temperature is rapidly increasing. Forpurposes of GPS coordinates, many GPS systems offer an indication ofaccuracy in relation to a currently indicated location. That is, the GPSgives some plus or minus tolerance distance from the currently indicatedlocation. Thus, a minimum accuracy can be specified which is indicatedas (+/−) D_(min) in Table 1.

-   -   Status of the portable device.    -   In this regard, a wide variety of data can be transferred via        telemetry from the portable device to the DAN hub and        subsequently stored and made available on the DAN server. Such        data can include, but is not limited to battery condition,        number of hours of operation remaining based on current battery        condition, software version, number of hours of operation, the        serial number of the device, a customer asset number, optional        features that have been installed, fault logs, current        latitude/longitude location, and the like. The DAN hub can        perform preprocessing on the data prior to transfer to the DAN        server, although no requirement is imposed in this regard. Such        preprocessing can be based, at least in part, on the available        bandwidth for Internet access or based on a priority need for        the data at the DAN server. For example, data relating to the        bore path for purposes of constructing an as-built drawing of        the bore path can be of high priority when there is a desire to        remotely monitor the progress of the inground operation in real        time. As another example, preprocessing can be based on        identifying violations of predefined threshold values, as        described above.    -   Status of drill head transmitter 32′    -   Much of the same information referenced above with respect to        the portable device may be transmitted and remotely monitored or        stored with respect to drill head transmitter 32′, including        without limitation battery condition and number of hours of        operation remaining based on current battery condition.    -   Status of the drill rig    -   Through the CAN-bus interface, the DAN Hub can compile rig usage        statistics, alerts and other information critical to the proper        maintenance of the rig.    -   Status of the DAN Hub        DAN Services

DAN Server 220 can process data collected by DAN Hub 210 to provide DANServices such as, for example:

-   -   Access to data logs collected during boring operations that can        be used to generate “as built” drawings    -   Remote monitoring of the progress of a particular boring        operation    -   Access to the status of all devices in the DAN, including the        DAN Hub, portable device(s), drill head transmitter and drill        rig

DAN Server 220 can push data to DAN devices, including:

-   -   Software updates for portable device 20    -   Software updates for drill head transmitter 32′    -   Software updates for drill rig 220    -   Software updates for DAN Hub 210 including, for example,        purchased applications that can be loaded and executed        on-the-fly    -   Map data from Geographical Information Services that is        displayed on screen 126    -   Other data such as information and advertising

FIG. 3 is a flow diagram which illustrates an embodiment of a method,generally indicated by the reference number 300, for performing DANcomponent updates. The method begins at 302 and proceeds to 304 forloading an update into DAN server 220 (FIGS. 1 and 2). The update can beplaced onto the DAN server, for example, by either LAN user 226 or WANuser 234. The update can then be transferred at 306 to DAN hub 210. Ofcourse, the update can be transferred to any number of DAN hubs sincethe update can be directed to any number of like DAN components that canbe distributed worldwide. Step 308 determines whether the update isdirected to portable device 20. If so, operation proceeds to 310 whichtransfers the update to the portable device via telemetry transceiver122, for example, on a UHF frequency band. The portable device can thenexecute the update. If step 308 determines that the update is notdirected to the portable device, operation proceeds to 312 whichdetermines whether the update is targeted to drill head transmitter 32′.If so, operation proceeds to 314 for transfer of the update to the drillhead transmitter via the IrDA link. If the drill head transmitter iscurrently engaged in an inground operation, of course, the update cannotbe performed until the drill head transmitter is available above ground.If step 312 determines that the update is not directed to the drill headtransmitter, operation proceeds to 316 which determines whether theupdate is directed to drill rig 80. If so, at 318, the update istransferred to the drill rig via the CAN-bus for installation viaCAN-bus protocol. If step 316 determines that the update does not targetthe drill rig, operation proceeds to 320 which checks whether the updateis directed to some other DAN component such as, for example, a tensionmonitoring arrangement that is used during a pull-back operation. If so,operation proceeds to step 322 for transferring the update to othercomponent and performing the update in a suitable manner. If step 320determines that the update is not directed to another component,operation returns to step 304. In this regard, operation also returns tostep 304 subsequent to any of steps 310, 314, 318 and 322. In someembodiments, the DAN hub can serve as a controller to dynamicallyconfigure certain operational parameters of system components, asdescribed immediately hereinafter.

As noted above governmental entities can impose a wide range ofdifferent requirements with respect to performing an inground operationin a given region. The existence of a drilling area network canfacilitate compliance with such regulations, for instance, byidentifying a geographic location at which the project is beingconducted and facilitating manual and/or automatic adjustment of theoperational parameters of related equipment to match such geographiclocation's regulatory requirements. It should be appreciated that suchoperational parameter updates can be handled via method 300 of FIG. 3.

Referring again to FIG. 1, control console 120 at the drill rig caninclude a GPS receiver 400, which is shown by way of non-limitingexample as part of telemetry transceiver 122, for receiving GPS signals402. The GPS receiver may include an updatable map that can bepre-loaded and/or can obtain map information on-the-fly via wirelessconnection 214. GPS receiver 400 is able to establish the currentlocation of the drill rig or other such system component on which theGPS receiver is located. Any suitable component of the system can serveas a locatable component such as, for example, portable device 20. In anembodiment, system 10 is able to identify a specific geographic regionin which the current operation is being performed and customize systemoperation as well as system components to conform to region specificparameters. The region specific parameters can be stored and accessed inany suitable manner. In one embodiment, the region specific parameterscan be stored by one or more of the local DAN components such as DAN hub210 and/or portable device 20. In another embodiment, the regionspecific parameters can be stored remotely on DAN server 220 andaccessed through the Internet. In still another embodiment, the regionspecific parameters can be stored on both DAN server 220 and on a localDAN component. The information on the DAN server can be periodicallyupdated by remote administrative personnel such that the DAN hub canperiodically update or synchronize locally stored information. As willbe further described, in some cases, region specific parameters aremandated through government authority while, in other cases, regionspecific parameters can represent other localized information. In stillother cases, local information can be provided to the operator for awide range of purposes.

Region specific parameters imposed by government authority such asregulatory agencies and/or law or regulation can include, by way ofnon-limiting example, specification of acceptable transmissionfrequencies and power (i.e., signal strength) limits in the region.Responsive to such specifications, DAN hub 210 can apply appropriatesettings to configurable components including but not limited totelemetry transceiver 122 at the drill rig and portable device 20 to usetelemetry signals 125 and 42, respectively, and can further configureunderground transceiver 32′ and portable device 20, respectively, totransmit and receive locating signal 30, at the appropriate frequenciesand power levels. In an embodiment, the system can be configured suchthat the operator is unable to override the specified frequency, poweror other parameters for the region. In another embodiment, the localauthority may provide options such as, for example, differentfrequencies or frequency bands, or other exceptions to the specifiedfrequency, power or other parameters may be accounted for. Othergovernment imposed parameters can include, for example, modulation typeand data rates, all of which can be accommodated. In an embodiment,identification of required settings such as, for example, transmissionsettings for frequency and signal strength, can cause the system toautomatically reconfigure to conform to the required settings.

Other localized information can include, by way of non-limiting example,language, time, date, time zone, units of temperature (such as degreesCentigrade or Fahrenheit) and units of measure (such as meters or feet).Local information may further include, by way of non-limiting example,any location based service such as local weather forecasts and/orweather alerts or local advertising.

Region profiles can be provided that are representative of particulargeographical regions, including but not limited to associations ofcountries such as, for example, the European Union, individualcountries, counties and cities. Each profile can provide a customizedversion of any combination of national and/or local governmentrequirements, standard practice requirements and local information.Profile information that is representative of operational requirementssuch as, for example, frequency and power settings can trigger automaticconfiguration of specified values.

Still referring to FIG. 1, system 10 can provide for remote trackingwith regard to the operation and/or configuration of any component ofthe DAN. For example, the usage of system components such as, forexample, locator 20 and drill rig 80 can be tracked in terms ofoperational hours. The GPS position of any GPS enabled components can betracked. By way of non-limiting example, other information can includemodel and serial numbers of system components, manufactureridentification for system components, customer ID's, and contractorinformation. Further, information of interest relating to any of thedata logs described above can be monitored. The occurrence of errorconditions can be tracked for any component. For example, a DANcomponent can be configured to issue an error code to DAN hub 210. Usinglocator 20 as an example, an error code can be issued by the locatorwith respect to the status of the internal battery reaching end-of-lifecondition. Another error code can relate to the need for an update of aninstalled software version. Parameters specific to the drill rig can bemonitored and recorded using the CAN-bus. All collected information canbe stored locally by DAN hub 210 and uploaded to DAN server 220 in theform of a field report when an Internet connection is available. In someinstances, the field report can effectively be no more than a fieldupdate or notification in which no more processing is applied than whatis necessary, such as formatting, to transfer essentially unprocessed,raw data to a remote location. Such raw data transmission can be usefulwhen sufficient bandwidth for the remote transfer is available. By wayof non-limiting example, raw data can include measurements associatedwith the inground tool including, for example, orientation, temperature,fluid pressure, push force and the like. In such embodiments, the DANserver or other remote component can perform any subsequent dataprocessing, analysis and manipulation that is desired and/or needed. Inother instances, a field report can be produced locally by the DAN hubto apply any level of processing and analysis that is necessary and cangenerate appropriate recommendations.

Such locally produced field reports can be produced solely by the DANhub, by an application running on the DAN hub or in cooperation with anapplication running on the DAN hub. In any case, the application can bea third party application. The DAN hub can utilize any locally availablecomponents and resources having processing power that can be brought tobear on the task of producing a field report in cooperation with the DANhub. Of course, the DAN hub can identify the available bandwidth of theInternet connection and initiate transfer of data responsive to apredetermined prioritization. Essentially any aspect of systemcomponents and/or operation that is susceptible to data characterizationcan be monitored by the system. Accordingly, a field report can includelocator-based and/or rig-based information to characterize at least oneof the inground operation, an operational condition of the downholetransceiver, an operational condition of the uphole transceiver, anoperational condition of the drill rig and an operational condition ofportable device 20.

The information stored at the DAN hub and/or transferred to the DANserver can be used in a wide variety of different ways. For example,notifications can be provided to the system operator based on theuploaded information. Again using locator 20 as an example, the operatorcan be notified by email that the locator battery is near end-of-lifeand should be replaced. Notifications can also be provided, for example,to indicate to the operator that an upgraded software version isavailable for the locator. In an embodiment, information relating to thecurrent operational region can be compared to the current operationalmode of the system and/or its components. In an embodiment, if thefrequency, power or other settings for the current operational region donot match current system settings, a notification can be providedlocally, for instance, on a component such as display 126 and stored byDAN hub 210. In one feature, the notification can be transferred to DANserver 220 such that remote notifications can be issued in any suitablemanner such as, for example, via email. Recommendations can comprise aform of notification and can encompass a broad range of subject matter.By way of non-limiting example, steering commands such as push, rotateand spin can comprise one form of recommendation to advise the operatorduring an ongoing drilling operation such that the drill head remains onand/or is returned to an intended path. Another form of recommendationcan warn that retraction of the drill string should immediately cease,for instance, in response to exceeding a tension threshold duringpull-back of a utility. Similarly, a recommendation may be generatedwarning to reduce or cease the flow of drilling mud in response to fluidpressure readings exceeding a threshold. Other recommendations canadvise changing a carrier frequency and/or parameter to conform toregion specific requirements, changing the locator battery, performingan equipment check based on the detection of any out-of-range conditionat the drill rig such as, for example, oil pressure, hydraulic pressure,mud pressure and the like. Other recommendations can relate toidentification of a cross-bore or frac-out and can encompass correctivesteps related to such conditions.

Information stored in DAN server 220 can serve as the basis for accessby a variety of different users and/or user groups. The DAN server caninclude applications that are customized for the manufacturer and atleast selected ones of the users and/or user groups. Specific usergroups that are of interest can include, by way of non-limiting example,distribution partners, customers, utility operators, contractors and anygovernment authorities such as municipalities that manage utilitydistribution systems. Information can be customized for presentation tothese various entities in any suitable manner and in a virtuallyunlimited number of ways.

An application on the DAN server that is customized for the manufacturercan provide for the entry of information relating to any aspect of auser and/or user group. For example, statistics relating to a particulardistribution partner can be entered.

The manufacturer and/or distribution partners can access the DAN serverfor purposes of supporting a customer base. In an embodiment, anapplication can monitor any service/maintenance related information forselected DAN components associated with a customer group. For example,the application can monitor software versions, maintenance schedules anderror codes for DAN components. The DAN server can generate a wide rangeof different custom reports based on the information that is availableat the DAN server. As another example, an application can allow adistribution partner to track the usage of DAN equipment such as, forexample, locating equipment to offer upgrades and services with respectto such equipment. The DAN server can generate custom reports for themanufacturer and/or distribution partner to provide for such usagetracking. Responsive to detecting an out-of-date condition or the needfor repair or maintenance of a DAN component, the application can notifythe manufacturer or distributor of one or more recommended actions suchthat they can respond directly. In an embodiment, a notification can besent directly to the customer, contractor or equipment operator. Again,the DAN server can generate relevant custom reports for the manufacturerand/or distribution partner for follow-up.

A user group that can be made up, for example, of utility operators andmunicipalities can access the DAN server for purposes of characterizinga utility installation of interest. In this case, a DAN serverapplication can access log records which are associated with the utilityinstallation and can generate related custom reports for transfer to oneor more entities that have an interest in any of the capturedinformation. In some cases, the manufacturer can specify that certaincustom reports and/or records are not available to a particular entityand/or type of entity. The application can be configured, for example,to generate as-built drawings of the installation in any desired viewincluding perspective views. Additional information can identify, in anysuitable combination, the installation date, particular equipment thatwas used to perform the operation and installation including the statusof the DAN components during the operation, any reported error codesassociated with the operation, identification of the installingcontractor, details with respect to the type of utility installed,maximum pull-back tension applied to the utility, statistics relating tomud pressure and/or drill head temperature during the drillingoperation, any available GPS coordinates that are associated with theoperation and so on. It should be appreciated that any available,relevant information can be included without limitation. Further, anyavailable statistic of interest or combination of statistics can beplotted for display.

Attention is now directed to FIG. 4 which is a block diagram of anembodiment of DAN hub 210. The hub can include a field report andnotification generator 400 that serves as an engine for relatedprocessing. Generator 400 is in bidirectional communication with anexternal communication interface 404 that can, in turn, be interfaced tothe Internet 212 for any needed external communication. A referencesection 408 can store operational parameters, priority tables such asaforedescribed Table 1 including priority assignments and thresholdvalues. Any other data of interest can also be stored in referencesection 408. For example, previously generated field reports can bestored prior to transfer to the DAN server. A data log section 412 canstore any data logs 414 that are of interest which can be updatedon-the-fly as incoming data is parsed amongst the various logs. By wayof example, the data logs can include inground tool depth 418 a,inground tool pitch 418 b, inground tool temperature 418 c, annularfluid pressure 418 d, pull-back tension 418 e, portable device status418 f, inground tool transceiver status 418 g, drill rig status 418 h,GPS or other-determined coordinates 418 i of system components, andother logs. A drill rig interface 422 can be in data communication withthe drill rig for collecting any information that is available fromvarious monitoring and sensor functions of the drill rig. Suchinformation can be available, for example, through CAN-Bus 242 of FIG.2. Parameters that can be sensed or monitored can include, but are notlimited to drill string clamp status, drill string extension/retraction,hydraulic pressure, drilling fluid status/pressure and flow rate at thedrill rig, drill string push force, drill string rotation rate, rigmotor RPM and the like. Of course, the drill rig interface data can betargeted to logs 414 and can be indexed against time and/or drill stringlength, as examples. A borepath data interface 426 can collect anyinformation that is available with respect to an ongoing ingroundoperation that is being performed. Generally, this data can be targetedto supplement data logs 414, with data logs 418 a-418 i serving asexamples of a wide range of data that can be received and loggedresponsive to movement of an inground tool along a borepath. It shouldbe appreciated that different data can be collected during differenttypes of inground operations such as, for example, a drilling operation,a back-reaming/pull-back operation and a mapping operation. A regionspecific parameter/geographic database 428 is provided for referenceagainst a currently identified location of any component of the system.It should be appreciated that the DAN hub provides a great degree offlexibility with respect to the implementation of DAN services. Forexample, the DAN hub can serve as a platform for applications 430 thatcan be provided by and/or tailored for a wide variety of different userentities such as the operator, contractor, distribution partner and/ormanufacturer. As is the case with the DAN server and in an embodiment,third-party applications can be supported and can be accessed, updatedand maintained through the Internet. It should be appreciated that theDAN hub can itself serve as a WiFi hotspot such that applications 430can be provided even for purposes of controlling system components suchas the drill rig or a portable device using a smartphone or tablet.

FIG. 5 is a flow diagram that illustrates an embodiment of a method forthe operation of the DAN hub, generally indicated by the referencenumber 500. The method begins at start 504 and moves to 508 to confirmwhich communication channels are available. For example, it can bedetermined whether the drill head transceiver is above or below ground.As another example, the external data communication bandwidth, if any,can be determined. At 512, priority values, thresholds and the log datastructure can be initialized. The priority system can be established,for example, based on Table 1. The current location of the system and/orcertain components can be determined and referenced against regionspecific parameter database 428 to determine proper systemconfiguration. The system configuration can be changed responsive tooperator prompting, automatic reconfiguration or some combinationthereof. Normal operation is then entered at 516. At 520, adetermination is made as to whether new borepath data is available. Ifso, operation proceeds to 524 which supplements the appropriate logsthat characterize the borepath as well as any measurements takentherealong. By way of non-limiting example, these logs can includeborepath mapped locations, borepath pitch, borepath yaw, pull-backtension, inground transceiver status, GPS coordinates, temperaturereadings, pressure readings and the like. If no new borepath data isavailable, operation proceeds to 528 which tests for new drill rigand/or DAN component data. A wide range of data can be subject tocapture responsive to this step including, but not limited to drillingfluid status, battery status and temperature of the downhole transceiverand battery status of the portable device. If new data is available,operation moves to 532 to supplement the appropriate logs. If no new rigand/or DAN component data is available, operation proceeds to 536 whichcan monitor for any other form of field data update that the drillingarea network can generate. If update data is available, the appropriatelogs are updated at 540. Subsequent to any of a determination that noother update data is available at 536, or completion of supplementingthe appropriate logs by steps 524, 532 and 540, operation proceeds to550 which determines whether a new field report should be generatedbased on new log updates. This determination can be made in any suitablemanner. For example, a field report can be generated responsive todetecting violation of any threshold. As another example, the generationof a field report can be triggered by the accumulation of some amount ofdata relating to a particular data log since the last field report wasgenerated. As another example, a field report can be generated based onsome value of incremental extension of the drill string. If it is notnecessary to generate a field report, normal operation resumes at 516.On the other hand, if it is necessary to generate the field report, thefield report can be generated and transferred at 554. In an embodiment,data logs can be transferred based on the particular type of data log inview of Table 1 or based on any suitable priority system. Subsequently,normal operation resumes at 516.

FIG. 6 is a block diagram of an embodiment of DAN server 220. Aprocessor 600 can be configured to control all the various functions ofthe DAN server. A LAN user interface 604 can provide for local access tothe server such as, for example, by the manufacturer. A WAN userinterface 608 can provide access by any external user of the system andcan allow the server to communicate with any DAN hubs that are inoperation around the world. A custom reports section 612 can provide forstoring previously generated custom reports as well as facilitatinggeneration of new custom reports. A notifications section 616 canprovide for storing previously generated notifications as well asfacilitating generation of new notifications. A field data section cancomprise an overall database that stores all collected field informationthat is received by the DAN server. The information can be compressedand/or encrypted, indexed and cross-indexed in any suitable manner. Forexample, information can be indexed based on the inground operationsthat are performed by a particular contractor. As another example,contractors can be indexed against distribution partners that serve assuppliers to a particular contractor base. A DAN component servicessection 624 can store any information relating to DAN components. Forexample, the operational status of any DAN component can be stored forpurposes of determining whether that component requires any sort ofmaintenance and/or software update. The DAN component information can beindexed and cross-indexed in any suitable manner such as, for example,based on the contractor who owns the equipment and the distributionpartner who sold the equipment to the contractor or services theequipment for the contractor. An as-built section 628 can store anyinformation relating to as-builts that can be or have been constructedrelating to particular inground operations. As-built information can beindexed in any suitable manner such as, for example, based on contractorand/or a utility owner or government entity. A region specific parametersection 630 can comprise worldwide specifications for operationalparameters and other regional information for reference by remote DANhubs.

Attention is now directed to FIG. 7 in conjunction with FIG. 6. Theformer illustrates an embodiment of a method for operation on DAN server220, generally indicated by the reference number 700. The method beginsat 704 and proceeds to 708 which accesses field data 620. Based on thefield data, at 712, it is determined by custom report section 612whether a custom report should be generated. Triggering events for thegeneration of a custom report can be based on a wide range ofoperational circumstances. For example, the accumulation of a certainamount of data with respect to a given inground operation can trigger acustom report. As another example, the completion of an ingroundoperation can result in the generation of a custom report. As stillanother example, any indication of a threshold violation condition or anerror condition can cause the system to generate a custom report. Asdescribed above, custom reports can be directed to any selected entityor entities that have access to the DAN server. If it is necessary togenerate a custom report, operation proceeds to 716 which collects thenecessary data and builds the custom report. The latter is transferredto the specified entity or entities at 720. In an embodiment, customreports can be transferred by text message and/or email. A determinationis then made at 724 as to whether new field data has been received bythe DAN server. If so, the field data is supplemented at 728. Operationthen returns to 708.

Returning to the discussion of step 712, if it is determined by customreport section 612 that is not necessary to generate a custom report,operation moves to 732 which determines, via notifications section 616,whether a notification should be issued to a particular entity orentities. By way of non-limiting example, notifications can be providedresponsive to error conditions as well as the violation of anythreshold. Responsive to determining the need to generate anotification, operation moves to 738 for the collection of appropriatedata and to build the notification. At 742, the notification istransferred to the appropriate entity or entities. In an embodiment,notifications can be transferred by text message and/or email. Operationthen returns to 724 which operates as described above. If 732 determinesthat a notification is not necessary, operation returns to 724 toestablish whether or not new field data has been collected. If so,operation proceeds to 728, as described above. Otherwise, step 724continues to monitor for the availability of new field data. It shouldbe appreciated that step 724 can timeout after some predeterminedinterval such that operation then returns to 728, even if no new fieldinformation has been collected. In this way, new custom reports andnotifications can be generated, for example, to indicate that noprogress is being made for a particular inground operation. Generally,however, method 700 will simultaneously be monitoring multiple ingroundoperations located around the world such that incoming data fromdifferent inground operations will occur in an overlapping manner andare appropriately handled. It should be appreciated that custom reportsand/or notifications can be generated responsive to monitoring DANcomponent services section 624 to indicate, for example, that an errorcondition has occurred in association with a particular DAN componentand/or that maintenance or service is needed. Further, a custom reportcan be generated responsive to the completion of an inground operationto collect and transfer data from as-built section 628 for generating anas-built. In this regard, as-built section 628 can comprise any data, inlog, form that can be used to construct an as-built for a givenin-ground operation. In addition to transfer of the data subsequent tocompletion of the inground operation, the data can be transferred inincremental custom reports. The comparison of these incremental customreports can be used to indicate potential problems that occurred duringan inground operation which would not otherwise be detectable, forexample, including data tampering.

In some embodiments, an individual user can customize a particularapplication for accessing and presenting information stored by the DANserver and/or the DAN hub. The concepts brought to light above withrespect to applications directed to the various users and user groupsabove can readily be provided as applications specific to popular mobiledevices such as, for example, smartphones and tablet computers.

The foregoing description of the invention has been presented forpurposes of illustration and description. It is not intended to beexhaustive or to limit the invention to the precise form or formsdisclosed. For example, the drilling area network of the presentdisclosure enables additional capabilities not previously available. Forinstance, industry-wide data may be collected, analyzed and used for avariety of commercial and research purposes. Companies who sellequipment or provide service can track usage remotely and introduceproducts and services, and/or provide remote customer service, based onsuch remotely-collected data.

Accordingly, a wide range of other modifications and variations may bepossible in light of the above teachings wherein those of skill in theart will recognize certain modifications, permutations, additions andsub-combinations thereof.

What is claimed is:
 1. An apparatus as part of a horizontal directionaldrilling system, said system including a drill rig and a portablelocator for monitoring the location of an inground tool along anunderground borepath, said apparatus comprising: a telemetry system forwireless bidirectional communication between the portable locator andthe drill rig, configured to transmit at least one telemetry signalhaving a transmission power and a transmit frequency; a geographicdatabase of region specific parameters that specifies operationalparameters based on location of said horizontal directional drillingsystem; an arrangement for identifying a current location of the systemand for correlating the current location with said geographic databaseto identify a set of local requirements for the telemetry signal at thecurrent location that specify at least one of a maximum transmissionpower and at least one transmission frequency for the telemetry signal;and a controller for setting at least one of the transmission power andthe transmit frequency to conform to the set of local requirements. 2.The apparatus of claim 1 wherein the set of local requirements specifiesat least one of a maximum transmission power and at least onetransmission frequency for said telemetry signal and the controller setsat least one of the transmission power and the transmit frequency basedon the specified maximum transmission power and the specifiedtransmission frequency.
 3. The apparatus of claim 1 wherein saidarrangement comprises a GPS receiver.